Voltage conservation using advanced metering infrastructure and substation centralized voltage control

ABSTRACT

A voltage control and conservation (VCC) system is provided, which includes three subsystems, including an energy delivery (ED) system, an energy control (EC) system and an energy regulation (ER) system. The VCC system is configured to monitor energy usage at the ED system and determine one or more energy delivery parameters at the EC system. The EC system may then provide the one or more energy delivery parameters to the ER system to adjust the energy delivered to a plurality of users for maximum energy conservation.

CROSS REFERENCE TO PRIOR APPLICATIONS

This application claims priority and the benefit thereof from a U.S.Provisional Application No. 61/176,398, filed on May 7, 2009 andentitled VOLTAGE CONSERVATION USING ADVANCED METERING INFRASTRUCTURE ANDSUBSTATION CENTRALIZED VOLTAGE CONTROL, the entirety of which is hereinincorporated by reference.

FIELD OF THE DISCLOSURE

The present disclosure relates to a method, an apparatus, a system and acomputer program for conserving energy. More particularly, thedisclosure relates to a novel implementation of voltage conservationusing advanced infrastructure and substation centralized voltagecontrol.

BACKGROUND OF THE DISCLOSURE

Electricity is commonly generated at a power station byelectromechanical generators, which are typically driven by heat enginesfueled by chemical combustion or nuclear fission, or driven by kineticenergy flowing from water or wind. The electricity is generally suppliedto end users through transmission grids as an alternating currentsignal. The transmission grids may include a network of power stations,transmission circuits, substations, and the like.

The generated electricity is typically stepped-up in voltage using, forexample, generating step-up transformers, before supplying theelectricity to a transmission system. Stepping up the voltage improvestransmission efficiency by reducing the electrical current flowing inthe transmission system conductors, while keeping the power transmittednearly equal to the power input. The stepped-up voltage electricity isthen transmitted through the transmission system to a distributionsystem, which distributes the electricity to end users. The distributionsystem may include a network that carries electricity from thetransmission system and delivering it to end users. Typically, thenetwork may include medium-voltage (for example, less than 69 kV) powerlines, electrical substations, transformers, low-voltage (for example,less than 1 kV) distribution wiring, electric meters, and the like.

The following describe subject matter related to power generation ordistribution: Power Distribution Planning Reference Book, SecondEdition, H. Lee Willis, 2004; Estimating Methodology for a LargeRegional Application of Conservation Voltage Reduction, J. G. De Steese,S. B. Merrick, B. W. Kennedy, IEEE Transactions on Power Systems, 1990;Implementation of Conservation Voltage Reduction at Commonwealth Edison,IEEE Transactions on Power Systems, D. Kirshner, 1990; and ConservationVoltage Reduction at Northeast Utilities, D. M. Lauria, IEEE, 1987.Further, U.S. Pat. No. 5,466,973, issued to Griffioen on Nov. 14, 1995,describes a method for regulating the voltage at which electric energyis supplied at the delivery points in a network for distributingelectricity.

The disclosure provides a novel method, apparatus, system and computerprogram for conserving energy in electric systems. More particularly,the disclosure provides a novel solution to conserve energy byimplementing voltage conservation using advanced infrastructure andsubstation centralized voltage control.

SUMMARY OF THE DISCLOSURE

According to an aspect of the disclosure, a voltage control andconservation (VCC) system is provided for monitoring, controlling andconserving energy. The VCC system comprises: a substation configured tosupply electrical power to a plurality of user locations; a smart meterlocated at one of the plurality of user locations and configured togenerate smart meter data based on a measured component of electricalpower received by the smart meter; and a voltage controller configuredto generate an energy delivery parameter based on the smart meter data,wherein the substation is further configured to adjust a voltage setpoint value of the electrical power supplied to the plurality of userlocations based on the energy delivery parameter, and wherein the smartmeter is configured to operate in a report-by-exception mode and suasponte send the smart meter data to the voltage controller when themeasured component of electrical power is determined to be outside of atarget component band.

The VCC system may further comprise a second smart meter located at asecond one of the plurality of user locations and configured to generatesecond smart meter data based on a second measured component ofelectrical power received by the second smart meter, wherein the voltagecontroller is further configured to determine an average user voltagecomponent by averaging the measured component of electrical powerreceived by the smart meter and the second measured component ofelectrical power received by the second smart meter.

The VCC system may further comprise a collector configured to receivethe smart meter data from the smart meter and generate collector data,wherein the voltage controller is further configured to generate theenergy delivery parameter based on the collector data.

In the VCC system, the target component band may include a targetvoltage band, and the voltage controller may be configured to comparethe measured component of electrical power received by the smart meterto the target voltage band and adjust the voltage set point based on aresult of the comparison.

The substation may comprise: a load tap change transformer that adjuststhe voltage set point value based on a load tap change coefficient; or avoltage regulator that adjusts the voltage set point value based on theenergy delivery parameter. The substation may comprise a distributionbus that supplies the electrical power to the plurality of userlocations, wherein an electrical power supply voltage component ismeasured on the distribution bus.

The voltage controller may comprise: a meter automation system server(MAS); a distribution management system (DMS); and a regional operationcenter (ROC). The voltage controller may be configured to adjust thevoltage set point at a maximum rate of one load tap change step. Thevoltage controller may be configured to adjust the voltage set pointbased on the average user voltage component. The voltage controller maybe configured to maintain the measured component of electrical powerreceived by the smart meter within the target voltage band based on theresult of the comparison. The voltage controller may be configured toselect said smart meter for monitoring and create a connection to saidsmart meter after receiving the smart meter data sent sua sponte by saidsmart meter while operating in the report-by-exception mode. The voltagecontroller may be configured to de-select another smart meter that waspreviously selected to be monitored. The voltage controller may beconfigured to create a connection to said smart meter and terminate aconnection to said another smart meter. The sua sponte smart meter datareceived from said smart meter may be representative of a low voltagelimiting level in the system. The voltage controller may be configuredto: store historical component data that includes at least one of anaggregated energy component data at a substation level, a voltagecomponent data at a substation level, and a weather data; determineenergy usage at each of the plurality of user locations; compare thehistorical component data to the determined energy usage; and determineenergy savings attributable to the system based on the results of thecomparison of the historical component data to the determined energyusage. The voltage controller may be configured to determine energysavings attributable to the system based on a linear regression thatremoves effects of weather, load growth, or economic effects. Thevoltage controller may be further configured to increase the voltage setpoint when either the electrical power supply voltage component or theaverage user voltage component falls below a target voltage band.

According to a further aspect of the disclosure, a VCC system isprovided that comprises: a substation configured to supply electricalpower to a plurality of user locations; a smart meter located at one ofthe plurality of user locations and configured to generate smart meterdata based on a measured component of electrical power received by thesmart meter; and a voltage controller configured to control a voltageset point of the electrical power supplied by the substation based onthe smart meter data. The smart meter may be configured to operate in areport-by-exception mode, which comprises sua sponte sending the smartmeter data to the voltage controller when the measured component ofelectrical power is determined to be outside of a target component band.

The VCC system may further comprise: a second smart meter located at asecond one of the plurality of user locations, the second smart meterbeing configured to generate second smart meter data based on a secondmeasured component of electrical power received by the second smartmeter, wherein the voltage controller is further configured to determinean average user voltage component by averaging the measured component ofelectrical power received by the smart meter and the second measuredcomponent of electrical power received by the second smart meter.

The substation may comprise: a load tap change transformer that adjuststhe voltage set point value based on a load tap change coefficient; or avoltage regulator that adjusts the voltage set point value based on theenergy delivery parameter. The substation may comprise a distributionbus that supplies the electrical power to the plurality of userlocations, wherein an electrical power supply voltage component ismeasured on the distribution bus.

The voltage controller may be configured to increase the voltage setpoint when either the electrical power supply voltage component or theaverage user voltage component falls below a target voltage band. Thevoltage controller may be configured to adjust the voltage set point ata maximum rate of one load tap change step. The voltage controller maybe configured to compare the measured component of electrical powerreceived by the smart meter to a target component band and adjust thevoltage set point based on a result of the comparison. The voltagecontroller may be configured to adjust the voltage set point based onthe average user voltage component. The target component band mayinclude a target voltage band, and the voltage controller may beconfigured to maintain the measured component of electrical powerreceived by the smart meter within the target voltage band based on theresult of the comparison.

According to a still further aspect of the disclosure, a method isprovided for controlling electrical power supplied to a plurality ofuser locations. The method comprises: receiving smart meter data from afirst one of the plurality of user locations; and adjusting a voltageset point at a substation based on the smart meter data, wherein thesmart meter data is sua sponte generated at the first one of theplurality of user locations when a measured component of electricalpower that is supplied to the first one of the plurality of userlocations is determined to be outside of a target component band.

The method may further comprise maintaining the average user voltagecomponent within the target voltage band. The method may furthercomprise measuring a voltage component of the supplied electrical poweron a distribution bus. The method may further comprise increasing thevoltage set point when either the electrical power supply voltagecomponent or an average user voltage component falls below the targetcomponent band. The method may further comprise: selecting said smartmeter for monitoring; and creating a connection to said smart meterafter receiving the smart meter data sent sua sponte by said smart meterwhile operating in a report-by-exception mode. The method may furthercomprise de-selecting another smart meter from a group of smart meterspreviously selected to be monitored. The method may further compriseterminating a connection to said another smart meter. The method mayfurther comprise: storing historical component data that includes atleast one of an aggregated energy component data at a substation level,a voltage component data at a substation level, and a weather data;determining energy usage at each of the plurality of user locations;comparing the historical component data to the determined energy usage;and determining energy savings attributable to the system based on theresults of the comparison of the historical component data to thedetermined energy usage. The target component band may include a targetvoltage band. The method may further comprise: determining the targetvoltage band; and comparing an average user voltage component to thetarget voltage band.

The voltage set point may be adjusted based on the result of comparingthe average user voltage component to the target voltage band. The suasponte smart meter data received from the smart meter may berepresentative of a low voltage limiting level in the system.

According to a still further aspect of the disclosure, a computerreadable medium is provided that tangibly embodies and includes acomputer program for controlling electrical power supplied to aplurality of user locations. The computer program comprises a pluralityof code sections, including: a receiving smart meter data code sectionthat, when executed on a computer, causes receiving smart meter datafrom a first one of the plurality of user locations; and a voltage setpoint adjusting code section that, when executed on a computer, causesadjusting a voltage set point at a substation based on the smart meterdata, wherein the smart meter data is sua sponte generated at the firstone of the plurality of user locations when a measured component ofelectrical power that is supplied to the first one of the plurality ofuser locations is determined to be outside of a target component band.

The computer program may comprise an average user voltage componentmaintaining code section that, when executed on the computer, causesmaintaining the average user voltage component within the target voltageband. The computer program may comprise a voltage component measuringcode section that, when executed on the computer, causes a voltagecomponent of the supplied electrical power to be measured on adistribution bus. The computer program may include a voltage set pointincreasing code section that, when executed on the computer, causesincreasing the voltage set point when either the electrical power supplyvoltage component or an average user voltage component falls below thetarget component band. The computer program may comprise: a smart meterselection code section that, when executed on the computer, causesselecting said smart meter for monitoring; and a connection creationcode section that, when executed on the computer, causes creating aconnection to said smart meter after receiving the smart meter data sentsua sponte by said smart meter while operating in a report-by-exceptionmode. The computer program may comprise a smart meter de-selecting codesection that, when executed on the computer, causes de-selecting anothersmart meter from a group of smart meters previously selected to bemonitored. The computer program may comprise connection terminating codesection that, when executed on the computer, causes terminating aconnection to said another smart meter.

The computer program may comprise: a storing code section that, whenexecuted on the computer, causes storing historical component data thatincludes at least one of an aggregated energy component data at asubstation level, a voltage component data at a substation level, and aweather data; an energy usage determining code section that, whenexecuted on the computer, causes determining energy usage at each of theplurality of user locations; a comparing code section that, whenexecuted on the computer, causes comparing the historical component datato the determined energy usage; and an energy savings determination codesection that, when executed on the computer, causes determining energysavings attributable to the system based on the results of thecomparison of the historical component data to the determined energyusage. The target component band may include a target voltage band. Thecomputer program may comprise: a target voltage band determining codesection that, when executed on the computer, causes determining thetarget voltage band; and a comparing code section that, when executed onthe computer, causes comparing an average user voltage component to thetarget voltage band. The voltage set point may be adjusted based on theresult of comparing the average user voltage component to the targetvoltage band. The sua sponte smart meter data received from the smartmeter may be representative of a low voltage limiting level in thesystem.

Additional features, advantages, and embodiments of the disclosure maybe set forth or apparent from consideration of the detailed descriptionand drawings. Moreover, it is to be understood that both the foregoingsummary of the disclosure and the following detailed description areexemplary and intended to provide further explanation without limitingthe scope of the disclosure as claimed.

BRIEF DESCRIPTION OF THE DRAWINGS

The accompanying drawings, which are included to provide a furtherunderstanding of the disclosure, are incorporated in and constitute apart of this specification, illustrate embodiments of the disclosure andtogether with the detailed description serve to explain the principlesof the disclosure. No attempt is made to show structural details of thedisclosure in more detail than may be necessary for a fundamentalunderstanding of the disclosure and the various ways in which it may bepracticed. In the drawings:

FIG. 1 shows an example of an electricity generation and distributionsystem, according to principles of the disclosure;

FIG. 2 shows an example of a voltage control and conservation (VCC)system, according to the principles of the disclosure;

FIG. 3 shows an example of a control screen that may be displayed on aregional operation center (ROC) computer, according to principles of thedisclosure;

FIG. 4 shows an example of a voltage control and conservation (VCC)process according to principles of the disclosure;

FIG. 5A shows an example of a process for monitoring the voltagecomponent and electrical energy received and measured at selected smartmeters, according to principles of the disclosure;

FIG. 5B shows an example of a process for selecting a smart meteroperating in a report-by-exception mode and de-selecting a previouslyselected smart meter, according to principles of the disclosure;

FIG. 6 shows an example of a graph of a voltage of electric powersupplied to users versus a time of day, according to principles of thedisclosure;

FIG. 7 shows an example of a graph of substation voltages of electricpower produced by, for example, an LTC transformer at a substation,which may be associated with, for example, the information displayed onthe control screen shown in FIG. 3;

FIG. 8 shows an example of data collected (including voltage and energymeasurement) hourly by the DMS in the example of FIG. 7, beforeapplication of the voltage control according to the principles of thedisclosure;

FIG. 9 shows an example of the data collected (including voltage andenergy measurement) hourly by the DMS in the example of FIG. 7, afterapplication of the voltage control according to the principles of thedisclosure;

FIG. 10 shows an example of calculation data for hours 1-5 and theaverage for the full twenty-four hours in the example of FIGS. 7-9;

FIG. 11 shows an example where data may be collected for weathervariables for the days before and after voltage control and/orconservation, according to principles of the disclosure;

FIG. 12 shows an example of an application of a paired test analysisprocess, according to principles of the disclosure;

FIG. 13 shows an example of a scatterplot of kW-per-customer days withVCC ON to kW-per-customer days with VCC OFF;

FIG. 14 shows an example of a summary chart for the data shown in FIG.13, according to principles of the disclosure;

FIG. 15 shows an alternative example of a scatterplot of historical databefore the VCC system is implemented, according to principles of thedisclosure;

FIG. 16 shows an alternative example of a scatterplot of historical dataafter the VCC system is implemented, according to principles of thedisclosure; and

FIG. 17 shows an alternative example of a summary chart, including 98%confidence intervals, according to principles of the disclosure.

The present disclosure is further described in the detailed descriptionthat follows.

DETAILED DESCRIPTION OF THE DISCLOSURE

The disclosure and the various features and advantageous details thereofare explained more fully with reference to the non-limiting embodimentsand examples that are described and/or illustrated in the accompanyingdrawings and detailed in the following description. It should be notedthat the features illustrated in the drawings are not necessarily drawnto scale, and features of one embodiment may be employed with otherembodiments as the skilled artisan would recognize, even if notexplicitly stated herein. Descriptions of well-known components andprocessing techniques may be omitted so as to not unnecessarily obscurethe embodiments of the disclosure. The examples used herein are intendedmerely to facilitate an understanding of ways in which the disclosuremay be practiced and to further enable those of skill in the art topractice the embodiments of the disclosure. Accordingly, the examplesand embodiments herein should not be construed as limiting the scope ofthe disclosure. Moreover, it is noted that like reference numeralsrepresent similar parts throughout the several views of the drawings.

A “computer”, as used in this disclosure, means any machine, device,circuit, component, or module, or any system of machines, devices,circuits, components, modules, or the like, which are capable ofmanipulating data according to one or more instructions, such as, forexample, without limitation, a processor, a microprocessor, a centralprocessing unit, a general purpose computer, a super computer, apersonal computer, a laptop computer, a palmtop computer, a notebookcomputer, a desktop computer, a workstation computer, a server, or thelike, or an array of processors, microprocessors, central processingunits, general purpose computers, super computers, personal computers,laptop computers, palmtop computers, notebook computers, desktopcomputers, workstation computers, servers, or the like.

A “server”, as used in this disclosure, means any combination ofsoftware and/or hardware, including at least one application and/or atleast one computer to perform services for connected clients as part ofa client-server architecture. The at least one server application mayinclude, but is not limited to, for example, an application program thatcan accept connections to service requests from clients by sending backresponses to the clients. The server may be configured to run the atleast one application, often under heavy workloads, unattended, forextended periods of time with minimal human direction. The server mayinclude a plurality of computers configured, with the at least oneapplication being divided among the computers depending upon theworkload. For example, under light loading, the at least one applicationcan run on a single computer. However, under heavy loading, multiplecomputers may be required to run the at least one application. Theserver, or any if its computers, may also be used as a workstation.

A “database”, as used in this disclosure, means any combination ofsoftware and/or hardware, including at least one application and/or atleast one computer. The database may include a structured collection ofrecords or data organized according to a database model, such as, forexample, but not limited to at least one of a relational model, ahierarchical model, a network model or the like. The database mayinclude a database management system application (DBMS) as is known inthe art. The at least one application may include, but is not limitedto, for example, an application program that can accept connections toservice requests from clients by sending back responses to the clients.The database may be configured to run the at least one application,often under heavy workloads, unattended, for extended periods of timewith minimal human direction.

A “communication link”, as used in this disclosure, means a wired and/orwireless medium that conveys data or information between at least twopoints. The wired or wireless medium may include, for example, ametallic conductor link, a radio frequency (RF) communication link, anInfrared (IR) communication link, an optical communication link, or thelike, without limitation. The RF communication link may include, forexample, WiFi, WiMAX, IEEE 802.11, DECT, 0G, 1G, 2G, 3G or 4G cellularstandards, Bluetooth, and the like.

The terms “including”, “comprising” and variations thereof, as used inthis disclosure, mean “including, but not limited to”, unless expresslyspecified otherwise.

The terms “a”, “an”, and “the”, as used in this disclosure, means “oneor more”, unless expressly specified otherwise.

Devices that are in communication with each other need not be incontinuous communication with each other, unless expressly specifiedotherwise. In addition, devices that are in communication with eachother may communicate directly or indirectly through one or moreintermediaries.

Although process steps, method steps, algorithms, or the like, may bedescribed in a sequential order, such processes, methods and algorithmsmay be configured to work in alternate orders. In other words, anysequence or order of steps that may be described does not necessarilyindicate a requirement that the steps be performed in that order. Thesteps of the processes, methods or algorithms described herein may beperformed in any order practical. Further, some steps may be performedsimultaneously.

When a single device or article is described herein, it will be readilyapparent that more than one device or article may be used in place of asingle device or article. Similarly, where more than one device orarticle is described herein, it will be readily apparent that a singledevice or article may be used in place of the more than one device orarticle. The functionality or the features of a device may bealternatively embodied by one or more other devices which are notexplicitly described as having such functionality or features.

A “computer-readable medium”, as used in this disclosure, means anymedium that participates in providing data (for example, instructions)which may be read by a computer. Such a medium may take many forms,including non-volatile media, volatile media, and transmission media.Non-volatile media may include, for example, optical or magnetic disksand other persistent memory. Volatile media may include dynamic randomaccess memory (DRAM). Transmission media may include coaxial cables,copper wire and fiber optics, including the wires that comprise a systembus coupled to the processor. Transmission media may include or conveyacoustic waves, light waves and electromagnetic emissions, such as thosegenerated during radio frequency (RF) and infrared (IR) datacommunications. Common forms of computer-readable media include, forexample, a floppy disk, a flexible disk, hard disk, magnetic tape, anyother magnetic medium, a CD-ROM, DVD, any other optical medium, punchcards, paper tape, any other physical medium with patterns of holes, aRAM, a PROM, an EPROM, a FLASH-EEPROM, any other memory chip orcartridge, a carrier wave as described hereinafter, or any other mediumfrom which a computer can read.

Various forms of computer readable media may be involved in carryingsequences of instructions to a computer. For example, sequences ofinstruction (i) may be delivered from a RAM to a processor, (ii) may becarried over a wireless transmission medium, and/or (iii) may beformatted according to numerous formats, standards or protocols,including, for example, WiFi, WiMAX, IEEE 802.11, DECT, 0G, 1G, 2G, 3Gor 4G cellular standards, Bluetooth, or the like.

According to one non-limiting example of the disclosure, a voltagecontrol and conservation (VCC) system 200 is provided (shown in FIG. 2),which includes three subsystems, including an energy delivery (ED)system 300, an energy control (EC) system 400 and an energy regulation(ER) system 500. The VCC system 200 is configured to monitor energyusage at the ED system 300 and determine one or more energy deliveryparameters C_(ED) at the EC system (or voltage controller) 400. The ECsystem 400 may then provide the one or more energy delivery parametersC_(ED) to the ER system 500 to adjust the energy delivered to aplurality of users for maximum energy conservation.

The VCC system 200 may be integrated into, for example, an existing loadcurtailment plan of an electrical power supply system. The electricalpower supply system may include an emergency voltage reduction plan,which may be activated when one or more predetermined events aretriggered. The predetermined events may include, for example, anemergency, a short circuit, an overheating of electrical conductors,when the electrical power output from the transformer exceeds, forexample, 80% of its power rating, or the like. The VCC system 200 isconfigured to yield to the load curtailment plan when the one or morepredetermined events are triggered, allowing the load curtailment planto be executed to reduce the voltage of the electrical power supplied tothe plurality of users.

FIG. 1 shows an example of an electricity generation and distributionsystem 100, according to principles of the disclosure. The electricitygeneration and distribution system 100 includes an electrical powergenerating station 110, a generating step-up transformer 120, asubstation 130, a plurality of step-down transformers 140, 165, 167, andusers 150, 160. The electrical power generating station 110 generateselectrical power that is supplied to the step-up transformer 120. Thestep-up transformer steps-up the voltage of the electrical power andsupplies the stepped-up electrical power to an electrical transmissionmedia 125.

As seen in FIG. 1, the electrical transmission media may include wireconductors, which may be carried above ground by, for example, utilitypoles 127 and/or under ground by, for example, shielded conductors (notshown). The electrical power is supplied from the step-up transformer120 to the substation 130 as electrical power E_(In)(t), where theelectrical power E_(In), in MegaWatts (MW) may vary as a function oftime t. The substation 130 converts the received electrical powerE_(In)(t) to E_(Supply)(t) and supplies the converted electrical powerE_(Supply)(t) to the plurality of users 150, 160. The substation 130 mayadjustably transform the voltage component V_(In)(t) of the receivedelectrical power E_(In)(t) by, for example, stepping-down the voltagebefore supplying the electrical power E_(Supply)(t) to the users 150,160. The electrical power E_(Supply)(t) supplied from the substation 130may be received by the step-down transformers 140, 165, 167 and suppliedto the users 150, 160 through a transmission medium 142, 162, such as,for example, but not limited to, underground electrical conductors(and/or above ground electrical conductors).

Each of the users 150, 160 may include an Advanced Meter Infrastructure(AMI) 155, 169. The AMI 155, 169 may be coupled to a Regional OperationsCenter (ROC) 180. The ROC 180 may be coupled to the AMI 155, 169, bymeans of a plurality of communication links 175, 184, 188, a network 170and/or a wireless communication system 190. The wireless communicationsystem 190 may include, but is not limited to, for example, an RFtransceiver, a satellite transceiver, and/or the like.

The network 170 may include, for example, at least one of the Internet,a local area network (LAN), a wide area network (WAN), a metropolitanarea network (MAN), a personal area network (PAN), a campus areanetwork, a corporate area network, a global area network (GAN), abroadband area network (BAN), or the like, any of which may beconfigured to communicate data via a wireless and/or a wiredcommunication medium. The network 170 may be configured to include anetwork topology such as, for example, a ring, a mesh, a line, a tree, astar, a bus, a full connection, or the like.

The AMI 155, 169 may include any one or more of the following: A smartmeter; a network interface (for example, a WAN interface, or the like);firmware; software; hardware; and the like. The smart meter may beconfigured to determine any one or more of the following:kilo-Watt-hours (kWh) delivered; kWh received; kWh delivered plus kWhreceived; kWh delivered minus kWh received; interval data; demand data;and the like. If the smart meter is a three phase meter, then the lowphase voltage may be used in the average calculation. If the meter is asingle phase meter, then the single voltage component will be averaged.

The AMI 155, 169 may further include one or more collectors (shown inFIG. 2) configured to collect smart meter data from one or more smartmeters tasked with, for example, measuring and reporting electric powerdelivery and consumption at one or more of the users 150, 160.Alternatively (or additionally), the one or more collectors may belocated external to the users 150, 160, such as, for example, in ahousing holding the step-down transformers 140, 165, 167. Each of thecollectors may be configured to communicate with the ROC 180.

VCC System 200

FIG. 2 shows an example of the VCC system 200, according to principlesof the disclosure. The VCC system 200 includes the ED system 300, the ECsystem 400 and the ER system 500, each of which is shown as abroken-line ellipse. The VCC system 200 is configured to monitor energyusage at the ED system 300. The ED system 300 monitors energy usage atone or more users 150, 160 (shown in FIG. 1) and sends energy usageinformation to the EC system 400. The EC system 400 processes the energyusage information and generates one or more energy delivery parametersC_(ED), which it sends to the ER system 500. The ER system 500 receivesthe one or more energy delivery parameters C_(ED) and adjusts theelectrical power E_(Supply)(t) supplied to the users 150, 160 based onthe received energy delivery parameters C_(ED).

The VCC system 200 minimizes power system losses, reduces user energyconsumption and provides precise user voltage control. The VCC system200 may include a closed loop process control application that uses uservoltage data provided by the ED system 300 to control, for example, avoltage set point V_(SP) on a distribution circuit (not shown) withinthe ER system 500. That is, the VCC system 200 may control the voltagesV_(Supply)(t) of the electrical power E_(Supply)(t) supplied to theusers 150, 160, by adjusting the voltage set point V_(SP) of thedistribution circuit in the ER system 500, which may include, forexample, one or more load tap changing (LTC) transformers, one or morevoltage regulators, or other voltage controlling equipment to maintain atighter band of operation of the voltages V_(Delivered)(t) of theelectric power E_(Delivered)(t) delivered to the users 150, 160, tolower power losses and facilitate efficient use of electrical powerE_(Delivered)(t) at the user locations 150 or 160.

The VCC system 200 controls or adjusts the voltage V_(Supply)(t) of theelectrical power E_(Supply)(t) supplied from the EC system 500 based onsmart meter data, which includes measured voltage V_(Meter)(t) data fromthe users 150, 160 in the ED system 300. The VCC system 200 may adjustthe voltage set point V_(SP) at the substation or line regulator levelin the ER system 500 by, for example, adjusting the LTC transformer (notshown), circuit regulators (not shown), or the like, to maintain theuser voltages V_(Meter)(t) in a target voltage band V_(Band-n), whichmay include a safe nominal operating range.

The VCC system 200 is configured to maintain the electrical powerE_(Delivered)(t) delivered to the users 150, 160 within one or morevoltage bands V_(Band-n). For example, the energy may be delivered intwo or more voltage bands V_(Band-n) substantially simultaneously, wherethe two or more voltage bands may be substantially the same ordifferent. The value V_(Band-n) may be determined by the followingexpression [1]:

V _(Band-n) =V _(SP) +ΔV  [1]

where V_(Band-n) is a range of voltages, n is a positive integer greaterthan zero corresponding to the number of voltage bands V_(Band) that maybe handled at substantially the same time, V_(SP) is the voltage setpoint value and ΔV is a voltage deviation range.

For example, the VCC system 200 may maintain the electrical powerE_(Delivered)(t) delivered to the users 150, 160 within a bandV_(Band-1) equal to, for example, 111V to 129V for rural applications,where V_(SP) is set to 120V and ΔV is set to a deviation ofseven-and-one-half percent (+/−7.5%). Similarly, the VCC system 200 maymaintain the electrical power E_(Delivered)(t) delivered to the users150, 160 within a band V_(Band-2) equal to, for example, 114V to 126Vfor urban applications, where V_(SP) is set to 120V and ΔV is set to adeviation of five (+/−5%).

The VCC system 200 may maintain the electrical power E_(Delivered)(t)delivered to the users 150, 160 at any voltage band V_(Band-n) usable bythe users 150, 160, by determining appropriate values for V_(SP) and ΔV.In this regard, the values V_(SP) and ΔV may be determined by the ECsystem 400 based on the energy usage information for users 150, 160,received from the ED system 300.

The EC system 400 may send the V_(SP) and ΔV values to the ER system 500as energy delivery parameters C_(ED), which may also include the valueV_(Band-n). The ER system 500 may then control and maintain the voltageV_(Delivered)(t) of the electrical power E_(Delivered)(t) delivered tothe users 150, 160, within the voltage band V_(Band-n). The energydelivery parameters C_(ED) may further include, for example,load-tap-changer (LTC) control commands.

The VCC system 200 may further measure and validate energy savings bycomparing energy usage by the users 150, 160 before a change in thevoltage set point value V_(SP) (or voltage band V_(Band-n)) to theenergy usage by the users 150, 160 after a change in the voltage setpoint value V_(SP) (or voltage band V_(Band-n)), according to principlesof the disclosure. These measurements and validations may be used todetermine the effect in overall energy savings by, for example, loweringthe voltage V_(Delivered)(t) of the electrical power E_(Delivered)(t)delivered to the users 150, 160, and to determine optimal deliveryvoltage bands V_(Band-n) for the energy power E_(Delivered)(t) deliveredto the users 150, 160.

ER System 500

The ER system 500 may communicate with the ED system 300 and/or ECsystem 400 by means of the network 170. The ER system 500 is coupled tothe network 170 and the EC system 400 by means of communication links510 and 430, respectively. The EC system 500 is also coupled to the EDsystem 300 by means of the power lines 340, which may includecommunication links.

The ER system 500 includes a substation 530 which receives theelectrical power supply E_(In)(t) from, for example, the powergenerating station 110 (shown in FIG. 1) on a line 520. The electricalpower E_(In)(t) includes a voltage V_(In)(t) component and a currentI_(In)(t) component. The substation 530 adjustably transforms thereceived electrical power E_(In)(t) to, for example, reduce (orstep-down) the voltage component V_(In)(t) of the electrical powerE_(In)(t) to a voltage value V_(Supply)(t) of the electrical powerE_(Supply)(t) supplied to the plurality of smart meters 330 on the powersupply lines 340.

The substation 530 may include a transformer (not shown), such as, forexample, a load tap change (LTC) transformer. In this regard, thesubstation 530 may further include an automatic tap changer mechanism(not shown), which is configured to automatically change the taps on theLTC transformer. The tap changer mechanism may change the taps on theLTC transformer either on-load (on-load tap changer, or OLTC) oroff-load, or both. The tap changer mechanism may be motor driven andcomputer controlled. The substation 530 may also include a buck/boosttransformer to adjust and maximize the power factor of the electricalpower E_(Delivered)(t) supplied to the users on power supply lines 340.

Additionally (or alternatively), the substation 530 may include one ormore voltage regulators, or other voltage controlling equipment, asknown by those having ordinary skill in the art, that may be controlledto maintain the output the voltage component V_(Supply)(t) of theelectrical power E_(Supply)(t) at a predetermined voltage value orwithin a predetermined range of voltage values.

The substation 530 receives the energy delivery parameters C_(ED) fromthe EC system 400 on the communication link 430. The energy deliveryparameters C_(ED) may include, for example, load tap coefficients whenan LTC transformer is used to step-down the input voltage componentV_(In)(t) of the electrical power E_(In)(t) to the voltage componentV_(Supply)(t) of the electrical power E_(Supply)(t) supplied to the EDsystem 300. In this regard, the load tap coefficients may be used by theER system 500 to keep the voltage component V_(Supply)(t) on thelow-voltage side of the LTC transformer at a predetermined voltage valueor within a predetermined range of voltage values.

The LTC transformer may include, for example, seventeen or more steps(thirty-five or more available positions), each of which may be selectedbased on the received load tap coefficients. Each change in step mayadjust the voltage component V_(Supply)(t) on the low voltage side ofthe LTC transformer by as little as, for example, about five-thousandths(0.5%), or less.

Alternatively, the LTC transformer may include fewer than seventeensteps. Similarly, each change in step of the LTC transformer may adjustthe voltage component V_(Supply)(t) on the low voltage side of the LTCtransformer by more than, for example, about five-thousandths (0.5%).

The voltage component V_(Supply)(t) may be measured and monitored on thelow voltage side of the LTC transformer by, for example, sampling orcontinuously measuring the voltage component V_(Supply)(t) of thestepped-down electrical power E_(Supply)(t) and storing the measuredvoltage component V_(Supply)(t) values as a function of time t in astorage (not shown), such as, for example, a computer readable medium.The voltage component V_(Supply)(t) may be monitored on, for example, asubstation distribution bus, or the like. Further, the voltage componentV_(Supply)(t) may be measured at any point where measurements could bemade for the transmission or distribution systems in the ER system 500.

Similarly, the voltage component V_(In)(t) of the electrical powerE_(In)(t) input to the high voltage side of the LTC transformer may bemeasured and monitored. Further, the current component I_(Supply)(t) ofthe stepped-down electrical power E_(Supply)(t) and the currentcomponent I_(In)(t) of the electrical power E_(In)(t) may also bemeasured and monitored. In this regard, a phase difference φ_(In)(t)between the voltage V_(In)(t) and current I_(In)(t) components of theelectrical power E_(In)(t) may be determined and monitored. Similarly, aphase difference φ_(Supply)(t) between the voltage V_(Supply)(t) andcurrent I_(Supply)(t) components of the electrical energy supplyE_(Supply)(t) may be determined and monitored.

The ER system 500 may provide electrical energy supply statusinformation to the EC system 400 on the communication links 430 or 510.The electrical energy supply information may include the monitoredvoltage component V_(Supply)(t). The electrical energy supplyinformation may further include the voltage component V_(In)(t), currentcomponents I_(In)(t), I_(Supply)(t), and/or phase difference valuesφ_(In)(t), φ_(Supply)(t), as a function of time t. The electrical energysupply status information may also include, for example, the load ratingof the LTC transformer.

The electrical energy supply status information may be provided to theEC system 400 at periodic intervals of time, such as, for example, everysecond, 5 sec., 10 sec., 30 sec., 60 sec., 120 sec., 600 sec., or anyother value within the scope and spirit of the disclosure, as determinedby one having ordinary skill in the art. The periodic intervals of timemay be set by the EC system 400 or the ER system 500. Alternatively, theelectrical energy supply status information may be provided to the ECsystem 400 or ER system 500 intermittently.

Further, the electrical energy supply status information may beforwarded to the EC system 400 in response to a request by the EC system400, or when a predetermined event is detected. The predetermined eventmay include, for example, when the voltage component V_(Supply)(t)changes by an amount greater (or less) than a defined threshold valueV_(SupplyThreshold) (for example, 130V) over a predetermined interval oftime, a temperature of one or more components in the ER system 500exceeds a defined temperature threshold, or the like.

ED System 300

The ED system 300 includes a plurality of smart meters 330. The EDsystem 300 may further include at least one collector 350, which isoptional. The ED system 300 may be coupled to the network 170 by meansof a communication link 310. The collector 350 may be coupled to theplurality of smart meters 330 by means of a communication link 320. Thesmart meters 330 may be coupled to the ER system 500 by means of one ormore power supply lines 340, which may also include communication links.

Each smart meter 330 is configured to measure, store and report energyusage data by the associated users 150, 160 (shown in FIG. 1). Eachsmart meter 330 is further configured to measure and determine energyusage at the users 150, 160, including the voltage componentV_(Meter)(t) and current component I_(Meter)(t) of the electrical powerE_(Meter)(t) used by the users 150, 160, as a function of time. Thesmart meters 330 may measure the voltage component V_(Meter)(t) andcurrent component I_(Meter)(t) of the electrical power E_(Meter)(t) atdiscrete times t_(s), where s is a sampling period, such as, forexample, s=5 sec., 10 sec., 30 sec., 60 sec., 300 sec., 600 sec., ormore. For example, the smart meters 330 may measure energy usage every,for example, minute (t_(60 sec)) five minutes (t_(300 sec)), ten minutes(t_(600 sec)), or more, or at time intervals variably set by the smartmeter 330 (for example, using a random number generator).

The smart meters 330 may average the measured voltage V_(Meter)(t)and/or I_(Meter)(t) values over predetermined time intervals (forexample, 5 min., 10 min., 30 min., or more). The smart meters 330 maystore the measured electrical power usage E_(Meter)(t) including themeasured voltage component V_(Meter)(t) and/or current componentI_(Meter)(t) as smart meter data in a local (or remote) storage (notshown), such as, for example, a computer readable medium.

Each smart meter 330 is also capable of operating in a“report-by-exception” mode for any voltage V_(Meter)(t), currentI_(Meter)(t), or energy usage E_(Meter)(t) that falls outside of atarget component band. The target component band may include, a targetvoltage band, a target current band, or a target energy usage band. Inthe “report-by-exception” mode, the smart meter 330 may sua sponteinitiate communication and send smart meter data to the EC system 400.The “report-by-exception” mode may be used to reconfigure the smartmeters 330 used to represent, for example, the lowest voltages on thecircuit as required by changing system conditions.

The smart meter data may be periodically provided to the collector 350by means of the communication links 320. Additionally, the smart meters330 may provide the smart meter data in response to a smart meter datarequest signal received from the collector 350 on the communicationlinks 320.

Alternatively (or additionally), the smart meter data may beperiodically provided directly to the EC system 400 (for example, theMAS 460) from the plurality of smart meters, by means of, for example,communication links 320, 410 and network 170. In this regard, thecollector 350 may be bypassed, or eliminated from the ED system 300.Furthermore, the smart meters 330 may provide the smart meter datadirectly to the EC system 400 in response to a smart meter data requestsignal received from the EC system 400. In the absence of the collector350, the EC system (for example, the MAS 460) may carry out thefunctionality of the collector 350 described herein.

The request signal may include, for example, a query (or read) signaland a smart meter identification signal that identifies the particularsmart meter 330 from which smart meter data is sought. The smart meterdata may include the following information for each smart meter 130,including, for example, kilo-Watt-hours (kWh) delivered data, kWhreceived data, kWh delivered plus kWh received data, kWh delivered minuskWh received data, voltage level data, current level data, phase anglebetween voltage and current, kVar data, time interval data, demand data,and the like.

Additionally, the smart meters 330 may send the smart meter data to themeter automation system server MAS 460. The smart meter data may be sentto the MAS 460 periodically according to a predetermined schedule orupon request from the MAS 460.

The collector 350 is configured to receive the smart meter data fromeach of the plurality of smart meters 330 via the communication links320. The collector 350 stores the received smart meter data in a localstorage (not shown), such as, for example, a computer readable medium.The collector 350 compiles the received smart meter data into acollector data. In this regard, the received smart meter data may beaggregated into the collector data based on, for example, a geographiczone in which the smart meters 330 are located, a particular time band(or range) during which the smart meter data was collected, a subset ofsmart meters 330 identified in a collector control signal, and the like.In compiling the received smart meter data, the collector 350 mayaverage the voltage component V_(Meter)(t) values received in the smartmeter data from all (or a subset of all) of the smart meters 330.

The EC system 400 is able to select or alter a subset of all of thesmart meters 330 to be monitored for predetermined time intervals, whichmay include for example 15 minute intervals. It is noted that thepredetermined time intervals may be shorter or longer than 15 minutes.The subset of all of the smart meters 330 is selectable and can bealtered by the EC system 400 as needed to maintain minimum level controlof the voltage V_(Supply)(t) supplied to the smart meters 330.

The collector 350 may also average the electrical power E_(Meter)(t)values received in the smart meter data from all (or a subset of all) ofthe smart meters 330. The compiled collector data may be provided by thecollector 350 to the EC system 400 by means of the communication link310 and network 170. For example, the collector 350 may send thecompiled collector data to the MAS 460 (or ROC 490) in the EC system400.

The collector 350 is configured to receive collector control signalsover the network 170 and communication link 310 from the EC system 400.Based on the received collector control signals, the collector 350 isfurther configured to select particular ones of the plurality of smartmeters 330 and query the meters for smart meter data by sending a smartmeter data request signal to the selected smart meters 330. Thecollector 350 may then collect the smart meter data that it receivesfrom the selected smart meters 330 in response to the queries. Theselectable smart meters 330 may include any one or more of the pluralityof smart meters 330. The collector control signals may include, forexample, an identification of the smart meters 330 to be queried (orread), time(s) at which the identified smart meters 330 are to measurethe V_(Meter)(t), I_(Meter)(t), E_(Meter)(t) and/or φ_(Meter)(t)(φ_(Meter)(t) is the phase difference between the voltage V_(Meter)(t)and current I_(Meter)(t) components of the electrical power E_(Meter)(t)al measured at the identified smart meter 330), energy usage informationsince the last reading from the identified smart meter 330, and thelike. The collector 350 may then compile and send the compiled collectordata to the MAS 460 (and/or ROC 490) in the EC system 400.

EC System 400

The EC system 400 may communicate with the ED system 300 and/or ERsystem 500 by means of the network 170. The EC system 400 is coupled tothe network 170 by means of one or more communication links 410. The ECsystem 400 may also communicate directly with the ER system 500 by meansof a communication link 430.

The EC system 400 includes the MAS 460, a database (DB) 470, adistribution management system (DMS) 480, and a regional operationcenter (ROC) 490. The ROC 490 may include a computer (ROC computer) 495,a server (not shown) and a database (not shown). The MAS 460 may becoupled to the DB 470 and DMS 480 by means of communication links 420and 440, respectively. The DMS 480 may be coupled to the ROC 490 and ERSYSTEM 500 by means of the communication link 430. The database 470 maybe located at the same location as (for example, proximate to, orwithin) the MAS 460, or at a remote location that may be accessible via,for example, the network 170.

The EC system 400 is configured to de-select, from the subset ofmonitored smart meters 330, a smart meter 330 that the EC system 400previously selected to monitor, and select the smart meter 330 that isoutside of the subset of monitored smart meters 330, but which isoperating in the report-by-exception mode. The EC system 400 may carryout this change after receiving the sua sponte smart meter data from thenon-selected smart meter 330. In this regard, the EC system 400 mayremove or terminate a connection to the de-selected smart meter 330 andcreate a new connection to the newly selected smart meter 330 operatingin the report-by-exception mode. The EC system 400 is further configuredto select any one or more of the plurality of smart meters 330 fromwhich it receives smart meter data comprising, for example, the lowestmeasured voltage component V_(Meter)(t), and generate an energy deliveryparameter C_(ED) based on the smart meter data received from the smartmeter(s) 330 that provide the lowest measured voltage componentV_(Meter)(t).

The MAS 460 may include a computer (not shown) that is configured toreceive the collector data from the collector 350, which includes smartmeter data collected from a selected subset (or all) of the smart meters330. The MAS 460 is further configured to retrieve and forward smartmeter data to the ROC 490 in response to queries received from the ROC490. The MAS 460 may store the collector data, including smart meterdata in a local storage and/or in the DB 470.

The DMS 480 may include a computer that is configured to receive theelectrical energy supply status information from the substation 530. TheDMS 480 is further configured to retrieve and forward measured voltagecomponent V_(Meter)(t) values and electrical power E_(Meter)(t) valuesin response to queries received from the ROC 490. The DMS 480 may befurther configured to retrieve and forward measured current componentI_(Meter)(t) values in response to queries received from the ROC 490.The DMS 480 also may be further configured to retrieve all“report-by-exception” voltages V_(Meter)(t) from the smart meters 330operating in the “report-by-exception” mode and designate the voltagesV_(Meter)(t) as one of the control points to be continuously read atpredetermined times (for example, every 15 minutes, or less (or more),or at varying times). The “report-by-exception voltages V_(Meter)(t) maybe used to control the EC 500 set points.

The DB 470 may include a plurality of relational databases (not shown).The DB 470 includes a large number of records that include historicaldata for each smart meter 330, each collector 350, each substation 530,and the geographic area(s) (including latitude, longitude, and altitude)where the smart meters 330, collectors 350, and substations 530 arelocated.

For instance, the DB 470 may include any one or more of the followinginformation for each smart meter 330, including: a geographic location(including latitude, longitude, and altitude); a smart meteridentification number; an account number; an account name; a billingaddress; a telephone number; a smart meter type, including model andserial number; a date when the smart meter was first placed into use; atime stamp of when the smart meter was last read (or queried); the smartmeter data received at the time of the last reading; a schedule of whenthe smart meter is to be read (or queried), including the types ofinformation that are to be read; and the like.

The historical smart meter data may include, for example, the electricalpower E_(Meter)(t) used by the particular smart meter 330, as a functionof time. Time t may be measured in, for example, discrete intervals atwhich the electrical power E_(Meter) magnitude (kWh) of the receivedelectrical power E_(Meter)(t) is measured or determined at the smartmeter 330. The historical smart meter data includes a measured voltagecomponent V_(Meter)(t) of the electrical energy E_(Meter)(t) received atthe smart meter 330. The historical smart meter data may further includea measured current component I_(Meter)(t) and/or phase differenceφ_(Meter)(t) of the electrical power E_(Meter)(t) received at the smartmeter 330.

As noted earlier, the voltage component V_(Meter)(t) may be measured ata sampling period of, for example, every five seconds, ten seconds,thirty seconds, one minute, five minutes, ten minutes, fifteen minutes,or the like. The current component I_(Meter)(t) and/or the receivedelectrical power E_(Meter)(t) values may also be measured atsubstantially the same times as the voltage component V_(Meter)(t).

Given the low cost of memory, the DB 470 may include historical datafrom the very beginning of when the smart meter data was first collectedfrom the smart meters 330 through to the most recent smart meter datareceived from the smart meter 330 s.

The DB 470 may include a time value associated with each measuredvoltage component V_(Meter)(t), current component I_(Meter)(t), phasecomponent φ_(Meter)(t) and/or electrical power E_(Meter)(t), which mayinclude a timestamp value generated at the smart meter 330. Thetimestamp value may include, for example, a year, a month, a day, anhour, a minute, a second, and a fraction of a second. Alternatively, thetimestamp may be a coded value which may be decoded to determine a year,a month, a day, an hour, a minute, a second, and a fraction of a second,using, for example, a look up table. The ROC 490 and/or smart meters 330may be configured to receive, for example, a WWVB atomic clock signaltransmitted by the U.S. National Institute of Standards and Technology(NIST), or the like and synchronize its internal clock (not shown) tothe WWVB atomic clock signal.

The historical data in the DB 470 may further include historicalcollector data associated with each collector 350. The historicalcollector data may include any one or more of the following information,including, for example: the particular smart meters 330 associated witheach collector 350; the geographic location (including latitude,longitude, and altitude) of each collector 350; a collector type,including model and serial number; a date when the collector 350 wasfirst placed into use; a time stamp of when collector data was lastreceived from the collector 350; the collector data that was received; aschedule of when the collector 350 is expected to send collector data,including the types of information that are to be sent; and the like.

The historical collector data may further include, for example, anexternal temperature value T_(Collector)(t) measured outside of eachcollector 350 at time t. The historical collector data may furtherinclude, for example, any one or more of the following for eachcollector 350: an atmospheric pressure value P_(Collector)(t) measuredproximate the collector 350 at time t; a humidity value H_(Collector)(t)measured proximate the collector 350 at time t; a wind vector valueW_(Collector)(t) measured proximate the collector 350 at time t,including direction and magnitude of the measured wind; a solarirradiant value L_(Collector)(t) (kW/m²) measured proximate thecollector 350 at time t; and the like.

The historical data in the DB 470 may further include historicalsubstation data associated with each substation 530. The historicalsubstation data may include any one or more of the followinginformation, including, for example: the identifications of theparticular smart meters 330 supplied with electrical energyE_(Supply)(t) by the substation 530; the geographic location (includinglatitude, longitude, and altitude) of the substation 530; the number ofdistribution circuits; the number of transformers; a transformer type ofeach transformer, including model, serial number and maximum MegavoltAmpere (MVA) rating; the number of voltage regulators; a voltageregulator type of each voltage regulator, including model and serialnumber; a time stamp of when substation data was last received from thesubstation 530; the substation data that was received; a schedule ofwhen the substation 530 is expected to provide electrical energy supplystatus information, including the types of information that are to beprovided; and the like.

The historical substation data may include, for example, the electricalpower E_(Supply)(t) supplied to each particular smart meter 330, whereE_(Supply)(t) is measured or determined at the output of the substation530. The historical substation data includes a measured voltagecomponent V_(Supply)(t) of the supplied electrical power E_(Supply)(t),which may be measured, for example, on the distribution bus (not shown)from the transformer. The historical substation data may further includea measured current component I_(Supply)(t) of the supplied electricalpower E_(Supply)(t). As noted earlier, the voltage componentV_(Supply)(t), the current component I_(Supply)(t), and/or theelectrical power E_(Supply)(t) may be measured at a sampling period of,for example, every five seconds, ten seconds, thirty seconds, a minute,five minutes, ten minutes, or the like. The historical substation datamay further include a phase difference value φ_(Supply)(t) between thevoltage V_(Supply)(t) and current I_(Supply)(t) signals of theelectrical power E_(Supply)(t), which may be used to determine the powerfactor of the electrical power E_(Supply)(t) supplied to the smartmeters 330.

The historical substation data may further include, for example, theelectrical power E_(In)(t) received on the line 520 at the input of thesubstation 530, where the electrical power E_(In)(t) is measured ordetermined at the input of the substation 530. The historical substationdata may include a measured voltage component V_(In)(t) of the receivedelectrical power E_(In)(t), which may be measured, for example, at theinput of the transformer. The historical substation data may furtherinclude a measured current component I_(In)(t) of the receivedelectrical power E_(In)(t). As noted earlier, the voltage componentV_(In)(t), the current component I_(In)(t) and/or the electrical powerE_(In)(t) may be measured at a sampling period of, for example, everyfive seconds, ten seconds, thirty seconds, a minute, five minutes, tenminutes, or the like. The historical substation data may further includea phase difference φ_(In)(t) between the voltage component V_(In)(t) andcurrent component I_(In)(t) of the electrical power E_(In)(t). The powerfactor of the electrical power E_(In)(t) may be determined based on thephase difference φ_(In)(t).

According to an aspect of the disclosure, the EC system 400 may saveaggregated kW data at the substation level, voltage data at thesubstation level, and weather data to compare to energy usage per smartmeter 330 to determine the energy savings from the VCC system 200, andusing linear regression to remove the affects of weather, load growth,economic effects, and the like, from the calculation.

In the VCC system 200, control may be initiated from, for example, theROC computer 495. In this regard, a control screen 305 may be displayedon the ROC computer 495, as shown, for example, in FIG. 3. The controlscreen 305 may correspond to data for a particular substation 530 (forexample, the TRABUE SUBSTATION) in the ER system 500. The ROC computer495 can control and override (if necessary), for example, the substation530 load tap changing transformer based on, for example, the smart meterdata received from the ED system 300 for the users 150, 160. The EDsystem 300 may determine the voltages of the electrical power suppliedto the user locations 150, 160, at predetermined (or variable)intervals, such as, e.g., on average each 15 minutes, while maintainingthe voltages within required voltage limits.

For system security, the substation 530 may be controlled through thedirect communication link 430 from the ROC 490 and/or DMS 480.

Furthermore, an operator can initiate a voltage control program on theROC computer 490, overriding the controls, if necessary, and monitoringa time it takes to read the user voltages V_(Meter)(t) being used forcontrol of, for example, the substation LTC transformer (not shown) inthe ER system 500.

FIG. 4 shows an example of a voltage control and conservation (VCC)process according to principles of the disclosure. The VCC process maybe carried out by, for example, but not limited to, the VCC system 200shown in FIG. 2.

Referring to FIGS. 2 and 4, a target voltage band V_(Band-n) may bedetermined for the voltage component V_(Meter)(t) of the electricalpower E_(Meter)(t) received and measured at the smart meters 330 (Step610). The target voltage band V_(Band-n) may be determined by setting avoltage set point value V_(SP) and a permissible voltage deviation rangeΔV according to the expression [1] V_(Band-n)=V_(SP)+ΔV. For instance,the voltage set point V_(SP) value may be set to 120V with a permissiblevoltage deviation of ΔV of five percent (+/−5%) for the target voltageband V_(Band-1). In this example, the target voltage band V_(Band-1)will be from about 114V (i.e., 120V−(120V×0.050)) to about 126V (i.e.,120V+(120V×0.050)).

The voltage component V_(Supply)(t) and electrical power E_(Supply)(t)values measured at substation 530 may be retrieved from the DMS 480(Step 620). The current, or most recent voltage component V_(Meter)(t)and electrical power E_(Meter)(t) values received and measured at theselected subset of the plurality of smart meters 330 may be retrievedfrom the MAS 460 (or a local storage, such as, for example, a computerreadable medium, in the ROC 490) (Step 630). The current, or most recentvoltage component V_(Meter)(t) and electrical power E_(Meter)(t) valuesmay have been measured by the select subset of smart meters 330 andforwarded to the MAS 460 via the collector 350, as described above.

Alternatively, the current, or most recent voltage componentV_(Meter)(t) and electrical power E_(Meter)(t) values may have beenretrieved directly from the collector 350 or the selected subset of thesmart meters 330 (Step 630).

The current, or most recent voltage component V_(Meter)(t) andelectrical power E_(Meter)(t) values may have been measured at theselected subset of smart meters 330 in response to a smart meter datarequest signal received from the collector 350. The collector 350 mayhave sent the smart meter data request signal in response to a collectorcontrol signal received from the MAS 460 (or the ROC 490).

The current, or most recent voltage component V_(Meter)(t) values may beaveraged for the selected number of smart meters 330 to determine anaverage voltage component V_(Meter-Avg)(t) value for the electricalpower delivered to the selected smart meters 330. This average voltagecomponent V_(Meter-Avg)(t) value may then be compared to the targetvoltage band V_(Band-n) to determine whether the average voltagecomponent V_(Meter-Avg)(t) value is within the target voltage bandV_(Band-n) (Step 650).

If the average voltage component V_(Meter-Avg)(t) value is outside ofthe target voltage band V_(Band-n), then a determination is made tochange the set point voltage V_(SP) of the voltage componentV_(Supply)(t) output by the substation 530 (YES at Step 660). Energydelivery parameters C_(ED) may be generated and sent to the substation530 to adjust the set point voltage V_(SP) of the output voltagecomponent V_(Supply)(t) (Step 670). A new voltage set point voltageV_(SP) value may be calculated by the DMS 480. Where a LTC transformeris used, the voltage set point voltage V_(SP) value may be increased (ordecreased) at a maximum rate of, for example, one volt about every, forexample, fifteen minutes (Note: for example, a 0.625% voltage change perstep in a LTC transformer). It is noted that the voltage set pointvoltage V_(SP) value may be increased (or decreased) at a rate of, forexample, a fraction of a volt, or multiple volts at one time. The energydelivery parameters C_(ED) may include, for example, load tapcoefficients. The set point voltage V_(SP) may be adjusted up (or down)by, for example, a fraction of a Volt (e.g., 0.01V, 0.02V, . . . , 0.1V,0.2V, . . . , 1.0V, . . . , or the like).

Furthermore, when either the V_(Supply)(t) or the V_(Meter-Avg)(t)voltage components reach or fall below a predetermined minimum voltagerange (for example, about 118V to about 119V), the set point voltageV_(SP) may be increased. When the voltage set point V_(SP) is raised,the V_(Supply)(t) or the V_(Meter-Avg)(t) voltage components shouldremain in a higher voltage band for, e.g., twenty-four hours before thevoltage set point V_(SP) may be lowered again.

If the average voltage component V_(Meter-Avg)(t) value is within thetarget voltage band V_(Band-n), then a determination is made not tochange the set point voltage V_(SP) of the voltage componentV_(Supply)(t) output by the substation 530 (NO at Step 660), and adetermination may be made whether to end the VCC process (Step 680). Ifa determination is made not to end the VCC process (NO at Step 680), theVCC process repeats.

According to an aspect of the disclosure, a computer readable medium isprovided containing a computer program, which when executed on, forexample, the ROC 495 (shown in FIG. 2), causes the VCC process accordingto FIG. 4 to be carried out. The computer program may be tangiblyembodied in the computer readable medium, comprising a code segment orcode section for each of the Steps 610 through 680.

FIG. 5A shows an example of a process for monitoring the voltagecomponent V_(Meter)(t) and electrical power E_(Meter)(t) received andmeasured at selected smart meters 330, according to an aspect ofdisclosure.

Referring to FIGS. 2 and 5A, initially a subset of smart meters 330 isselected from the smart meters 330 that are coupled to the power lines340, which are supplied with the electrical energy E_(Supply)(t) outfrom the substation 530 (Step 710). The subset may include, for example,one or more (or all) of the smart meters 330 that are selected randomlyor based on predetermined criteria. The predetermined criteria mayinclude, for example, historical smart meter data, weather conditions,geographic area, solar irradiation, historical energy usage associatedwith particular smart meters 330, and the like. The smart meters 330 maybe selected, for example, at the ROC 490 or MAS 460.

A schedule may be generated to obtain smart meter data from the selectedsubset of smart meters 330 (Step 720). The schedule may include, forexample, measuring the received voltage component V_(Meter)(t) andelectrical power E_(Meter)(t) every, for example, five seconds, tenseconds, thirty seconds, one minute, five minutes, ten minutes, fifteenminutes, or the like, at the selected subset of smart meters 330. Thegenerated schedule is provided to the collector 350 that is associatedwith the selected subset of smart meters 330 as part of a collectorcontrol signal (Step 730). The collector control signal may be generatedat, for example, the ROC 490 or MAS 460 and sent to the collector 350via communication link 410 and network 170.

The collector 350, based on the provided collector control signal or apreviously received schedule, may send a smart meter data request signalto the selected subset of smart meters 330 via communication links 320.The smart meter data request signal may include, for example, theschedule provided in the collector control signal. The schedule may bestored at the selected subset of smart meters 330 and used by the smartmeters 330 to control monitoring and reporting of the received voltagecomponent V_(Meter)(t) and electrical power E_(Meter)(t) for theassociated user 150 (160).

The collector 350 receives the reported smart meter data, including thevoltage component V_(Meter)(t) and electrical energy E_(Meter)(t) forthe associated user 150 (160), from the selected subset of smart meters330 via communication links 320. The collector 350 compiles the receivedsmart meter data, generating collector data and sending the collectordata to the EC system 400.

The collector data is received from the collector 350 (Step 740) andstored locally (or remotely) in the EC system 400 (Step 750). Inparticular, the received collector data is stored locally in, forexample, the ROC 490, the MAS 460 and/or the DB 470.

According to an aspect of the disclosure, a computer readable medium isprovided containing a computer program, which when executed on, forexample, the ROC 495 (shown in FIG. 2), causes the process formonitoring the voltage component and electrical power to be carried outaccording to FIG. 5A. The computer program may be tangibly embodied inthe computer readable medium, comprising a code segment or code sectionfor each of the Steps 710 through 750.

FIG. 5B shows an example of a process for selecting a smart meter 330operating in a report-by-exception mode and de-selecting a previouslyselected smart meter, according to principles of the disclosure.

Referring to FIG. 2 and FIG. 5B, the EC system 400 is configured tolisten or monitor for sua sponte smart meter data that may be receivedfrom one or more of the smart meters 330 operating in thereport-by-exception mode (Step 760). If sua sponte smart meter data isreceived from a particular smart meter 330 (YES, at Step 760), then theEC system 400 will proceed to select that particular smart meter 330(Step 765) and create a communication link to the smart meter 330 (Step770), otherwise the EC system 400 continues to monitor for sua spontesmart meter data (NO, at Step 760). The EC system 400 de-selects apreviously selected smart meter 330 (Step 775), which was selected aspart of the subset smart meters 330 to be monitored from the pluralityof smart meters 330, and terminates the communication link to thede-selected smart meter 330 (Step 780). The EC system 400 may use thesua sponte smart meter data to determine a voltage set point and providethe voltage set point to the ER system 500 to adjust the voltage setpoint (Step 785).

According to an aspect of the disclosure, a computer readable medium isprovided containing a computer program, which when executed on, forexample, the ROC 495 (shown in FIG. 2), causes the process for selectinga smart meter 330 operating in a report-by-exception mode andde-selecting a previously selected smart meter. The computer program maybe tangibly embodied in the computer readable medium, comprising a codesegment or code section for each of the Steps 760 through 785.

FIG. 6 shows an example of a graph of a voltage of electric powersupplied to users 150, 160, versus a time of day, according toprinciples of the disclosure. In particular, the upper waveform 805shows an example of voltage fluctuations in the electrical powerdelivered to the users 150, 160, without the VCC system 200. The lowerwaveform 808 shows an example of voltage fluctuations in the electricpower delivered to users 150, 160, with the VCC system 200. The area 807between the upper waveform 805 and lower waveform 808 corresponds to theenergy saved using the VCC system 200.

As seen in FIG. 6, the lower waveform 808 includes a tighter range(lower losses) of voltage fluctuations compared to the upper waveform805, which experiences higher voltage fluctuations and increased losses,resulting in substantially reduced power losses for the lower waveform808. For example, the voltage 805 may fluctuate between about 114V andabout 127V. Whereas, in the VCC system 200, the voltage waveform 808fluctuation may be reduced to, for example, between about 114V and about120V. As seen in the graph, the VCC system 200 may provide conservationthrough, for example, avoided energy imports and behind-the-metersavings. Further, the VCC system 200 may provide high confidence levelof savings without having to depend on the actions of the users 150,160.

FIG. 7 shows an example of a waveform 810 of substation voltagesV_(Supply)(t) of electric power produced by, for example, an LTCtransformer at the substation 530, which may be associated with, forexample, the information displayed on the control screen 305 shown inFIG. 3. A waveform 820 shows an average of, for example, twenty lowestlevel (or worst case) user voltages V_(Meter)(t) (for example, the tenworst voltages on one distribution circuit averaged with the ten worstvoltages on another distribution circuit) monitored at any one time ontwo distribution circuits that supply, for example,six-thousand-four-hundred users 150, 160 (shown in FIG. 1) withelectrical power during a period of time. In particular, the graph 810shows an example of voltage fluctuations (for example, an average ofvoltage 812 fluctuations and voltage 814 fluctuations on the pair ofcircuits, respectively) in the electrical power produced by thesubstation 530 (for example, the TRABUE SUBSTATION in FIG. 3) and thevoltage 820 fluctuations (for example, on the pair of circuits) in theelectrical power delivered to the users 150, 160.

The waveforms 810 and 820 prior to time to show an example of voltagefluctuations in the electrical power E_(Supply)(t) supplied by thesubstation 530 and electrical power E_(Meter)(t) received by the users150, 160, without the VCC system 200. The waveforms 810 and 820 aftertime t₀ show an example of voltage fluctuations in the electrical powerE_(Supply)(t) supplied by the substation 530 and electrical powerE_(Meter)(t) received by the users 150, 160, with the VCC system 200. Asseen in FIG. 7, before voltage control was applied (i.e., before t₀),the voltages 812, 814 (with an average voltage signal 810) of theelectrical power E_(Supply)(t) supplied by the substation 530 generallyfluctuated between, for example, about 123V and about 126V; and thevoltage waveform 820 of the electrical power E_(Meter)(t) received bythe users 150, 160, generally fluctuated between, for example, about121V and 124V. After voltage control was applied, the voltage waveforms812, 814 (810) generally fluctuated between, for example, about 120V andabout 122V, and the voltage waveform 820 generally fluctuated between,for example, about 116V and about 121V. Accordingly, the VCC system 200is able to operate the users 150, 160, in a lower band level.

Energy savings 807 (shown in FIG. 6) that result from operation of theVCC system 200, according to principles of the disclosure, may bemeasured and/or validated by measuring the voltage componentV_(Supply)(t) and electrical power E_(Supply)(t) levels of electricpower supplied by the substation 530 relative to the correspondingreference voltage set point V_(SP)(t) value. In the example shown inFIG. 7, the voltage V_(Supply)(t) and electrical energy E_(Supply)(t)levels may be measured at the transformer output (not shown) where thevoltage control may be implemented. However, the measurement may beperformed at any point where measurements could be made for thetransmission or distribution systems.

FIG. 8 shows an example of data collected (including voltage and energymeasurement) hourly by the DMS 480 (shown in FIG. 2), before time t₀(shown in FIG. 7), when voltage control is not carried out in the VCCsystem 200. As seen in FIG. 8, the collected data may include, forexample, a date, a time (hour:minute:second), a power level (MWatt), areactive power level (MVAr), a voltage (V), an apparent power level(MVA), a power factor (PF), loss factor, and loss FTR, of the electricalpower E_(Supply)(t) output by the substation 530.

FIG. 9 shows an example of data collected (including voltage and energymeasurement) hourly by the DMS 480 (shown in FIG. 2), after time t₀(shown in FIG. 7), when voltage control is carried out in the VCC system200. As seen in FIG. 9, the collected data may include, for example, adate, a time (hour:minute:second), a power level (MWatt), a reactivepower level (MVAr), a voltage (V), an apparent power level (MVA), apower factor (PF), load financial transmission rights (FTR), and lossFTR, of the electrical power E_(Supplied)(t) output by the substation530 with voltage control carried out by the VCC system 200.

Comparing the data in FIG. 8 to data of FIG. 9, the voltageV_(Supply)(t) and electrical power E_(Supply)(t) measurements show thesubstantial impact of lowering voltage on the electric power usage by,for example, users 150, 160. In this regard, the hourly data at atransformer (not shown) in the substation 530 (shown in FIG. 2) may besaved hourly. Voltage control and/or conservation may be carriedaccording to the principles of the disclosure, and the energy use before(FIG. 8) and after (FIG. 9) implementation of the VCC system 200 may becompared at the two different voltage levels along the distributioncircuit (for example, from or in the substation 530). In the examplesshown in FIGS. 8 and 9, the before voltages may range from, for example,about 123V to about 125V, and the after voltages may range from, forexample, about 120V to about 122V.

As shown in FIG. 7, the VCC system 200 can monitor the twenty worst casevoltages supplied by the distribution circuits and control the sourcebus voltage V_(SP)(t) to maintain the operation in the lower band, asshown, for example, in FIG. 6. The VCC system 200 can also reselect thesmart meters 330 used for the 20 worse case voltages based on, forexample, the information received from the EC system 400“report-by-exception” monitoring of voltage. The VCC system 200 mayselect these new smart meters 330 from the total number of smart meters330 connected to the substation 530.

The voltage V_(Supply)(t) and electrical power E_(Supply)(t) data shownin FIGS. 8 and 9 may be arranged by hour and averaged over twenty-fourhour periods, retaining the correct average of voltage to electricalpower (MW) by calculating the voltage to electrical power (MW) value foreach hour, adding for the twenty-four hours, calculating the weightedtwenty-four hour voltage using the average hourly electrical power (MW)value and the total twenty-four hour electrical power (MW) to Voltageratio for the day. This may produce one value for average electricalpower (MW) per hour for a twenty-four hour period and a weighted voltageassociated with this average electrical power usage.

FIG. 10 shows an example of calculation data for hours 1-5 and theaverage for the full twenty-four hours in the example of FIGS. 7-9.

FIG. 11 shows an example where data may be collected for weathervariables for the days before and after voltage control and/orconservation by the VCC system 200 according to the disclosure. Inparticular, FIG. 11 shows the data collected from the National WeatherService for, for example, Richmond International Airport, the nearestweather station location to the TRABUE SUBSTATION (shown in FIG. 3). Thedata shown is for the same period as the example of FIG. 7. The datashown in FIG. 11 may be used to eliminate as much of the changes inpower, other than those caused by voltage, to provide as accurate ameasurement as possible.

FIG. 12 shows an example of an application of the paired test analysisprocess, according to principles of the disclosure. As seen, kW usageper customer per day in the time period from May to January when, forexample, the VCC is in the OFF mode, is compared to kW usage percustomer per day in the time period from January to November when, forexample, the VCC is the ON mode. The Trabue Load growth demonstrates theprocess of pairing the test days from state 1 to state 2. Days from thepair 1 are picked from the May through January time period with voltageconservation turned OFF and matched with the days from the pair 2 periodfrom, for example, January through November. The match may be based onthe closest weather, season, day type, and relative humidity levels toremove as many other variables as possible, except for the change involtage. Because the data is collected over a long period of time, whereeconomic and growth can also impact the comparison of thecharacteristics of growth or economic decline are removed by using thekW-per-customer data to remove effects in customer energy usageincreases and decreases and a monthly linear regression model to removethe growth or economic decline correlated to the month with the weathervariables removed.

FIG. 13 shows an example of a scatterplot of a total power pertwenty-four hours versus heating degree day. In this regard, the voltageand electrical power (MW) per hour may be recorded, and average voltageand electrical power (MW) per hour determined for a twenty-four hourperiod. The scatterplot may be used to predict the power requirementsfor the next day using the closest power level day from the historicaldata stored in DB 470 (shown in FIG. 2). The calculation may use asinputs the change in the variables from the nearest load day to the daybeing calculated and the output may be the new load level. Using theseinputs and a standard linear regression calculation a model may be builtfor the historical data. The regression calculation may include, forexample, the following expression [2]:

E _(Total/Customer)=−4.54−0.260D _(Season)−0.213D_(Type)+0.0579H+0.0691V _(Avg)+0.00524D _(Month)  [2]

where: E_(Total) is a total power for a twenty-four hour period percustomer for a particular day; D_(Type) is a day type (such as, forexample, a weekend, a weekday, or a holiday) of the particular day;D_(Season) is one of four seasons corresponding to the particular day inthe calendar year; D_(Month) is the particular day in the month; H is aHeating Degree Day level for the particular day; and V is the V_(Avg)average voltage supplied per customer for the particular day.

The data shown in the example of FIG. 13 includes historic data for a115 day period, before the VCC system 200 is implemented according toprinciples of the disclosure. The example shown in FIG. 12 maycorrespond to a winter season for TRABUE SUBSTATION loads. As seen inFIG. 13, the model may be used represent the change in power level fromone day to the next that is not related to the weather, growth, andeconomic variables in the linear regression expression [2].

The historical data may be adjusted to match the heating degree daylevel for the measurements taken after the voltage control and/orconservation is carried out by the VCC system 200. For example,referring to FIG. 11, a heating degree day of 19 may be read for aparticular day, Feb. 1, 2009. The historical data may be searched in theDB 470 for all days with heating degree levels of 19. For example, twodays in December may be found with the same heating degree daylevels—for example, December 1 and 17. The linear regression modelexpression [2] for the historical data may be used to adjust thevariables for December 1 and 17 to the same values as the data taken onFeb. 1, 2009. This may provide as close a match between the historical(operating at the higher voltage level) and Feb. 1, 2009 (operating atthe lower voltage level). The calculation of (change in MW)/(change inVoltage) may be made from the high voltage to the low voltage operation.This may become one data point for the statistical analysis.

This process may be repeated for all measurements taken after thevoltage conservation is turned on and compared to all similar days inthe historical data taken for the matching season and other weatherconditions. This may produce, for example, one-hundred-fifteen datapoints from, for example, 115 days of operation matched with all of thehistorical matching data. The resulting statistical analysis of thisdata is shown in FIGS. 13-14.

The normality of the data may be validated using the Anderson-DarlingNormality test. In the case of the example of FIGS. 13 and 14, theP-Value may be 0.098, which may be well above the required value of0.01, thereby demonstrating that the data may be normal with anapproximately 99% confidence level, as shown in FIG. 14. This allows theapplication of a one sample T test to demonstrate the average of themean value of the change in electrical power (MW) to change in voltage.The test may be performed to evaluate the statistical significance ofthe average value being above, for example, about 1.0. As shown in FIG.14 the test may demonstrate an approximately 99% confidence level thatthe savings in power to reduction in voltage may be above about 1.0% per1% of voltage change. Using this type of statistical method continuoustracking of the energy saving improvement can be accomplished andrecorded in kW/customer saved per day or aggregated to total kW savedfor the customers connected to the substation 530.

FIG. 15 shows an alternative example of a scatterplot of a total powerper twenty-four hours versus heating degree day. In this regard, thevoltage and electrical power (MW) per hour may be recorded, and averagevoltage and electrical power (MW) per hour determined for a twenty-fourhour period. The scatterplot may be used to predict the powerrequirements for the next day using the closest power level day from thehistorical data stored in DB 470 (shown in FIG. 2). The calculation mayuse as inputs the change in the variables from the nearest load day tothe day being calculated and the output may be the new load level. Usingthese inputs and a standard linear regression calculation a model may bebuilt for the historical data. The regression calculation may include,for example, the following expression [3]:

$\begin{matrix}{E_{Total} = {\left( {{- 801} + {0.069Y} + {0.0722D_{Type}} + {0.094D_{Year}} + {0.0138D_{Month}} + {0.126T_{\max}} + {0.131T_{\min}} + {9.84T_{avg}} + {10.1H} - {10.3C} + {0.251P_{{Std}.}}} \right) - \left( {{0.102T_{\max - d}} - {0.101T_{\min - d}} + {0.892T_{{avg} - d}} + {0.693H_{d}} - {0.452C_{d}} - {0.025P_{R}} + {0.967E_{TotalPrevious}}} \right)}} & \lbrack 3\rbrack\end{matrix}$

where: E_(Total) is a total power for a twenty-four hour period for aparticular day; Y is a calendar year of the particular day; D_(Type) isa day type (such as, for example, a weekend, a weekday, or a holiday) ofthe particular day; D_(Year) is the particular day in the calendar year;D_(Month) is the particular day in the month; T_(max) is a maximumtemperature for the particular day; T_(min) is minimum temperature forthe particular day; T_(avg) is the average temperature for theparticular day; H is a Heating Degree Day level for the particular day;C is a Cooling Degree Day level; P_(Std) is a barometric pressure forthe particular day; T_(max-d) is a maximum temperature for a closestcomparison day to the particular day; T_(min-d) is minimum temperaturefor the closest comparison day to the particular day; T_(avg-d) is theaverage temperature for the closest comparison day to the particularday; H_(d) is a Heating Degree Day level for the closest comparison dayto the particular day; C_(d) is a Cooling Degree Day level for theclosest comparison day to the particular day; P_(R) is a Barometricpressure for the closest comparison day to the particular day; andE_(TotalPrevious) is the total average hourly usage in MW on the closestcomparison day to the particular day. The data shown in the example ofFIG. 15 includes historic data for a fifty day period, before the VCCsystem 200 is implemented according to principles of the disclosure. Theexample shown in FIG. 15 may correspond to a winter season for TRABUESUBSTATION loads. As seen in FIG. 15, the model may represent 99.7% ofthe change in power level from one day to the next using the variablesin the linear regression expression [3].

The historical data may be adjusted to match the heating degree daylevel for the measurements taken after the voltage control and/orconservation is carried out by the VCC system 200. For example,referring to FIG. 11, a heating degree day of 19 may be read for aparticular day, Feb. 1, 2009. The historical data may be searched in theDB 470 for all days with heating degree levels of 19. For example, twodays in December may be found with the same heating degree daylevels—for example, December 1 and 17. The linear regression modelexpression [3] for the historical data may be used to adjust thevariables for December 1 and 17 to the same values as the data taken onFeb. 1, 2009. This may provide as close a match between the historical(operating at the higher voltage level) and Feb. 1, 2009 (operating atthe lower voltage level). The calculation of (change in MW)/(change inVoltage) may be made from the high voltage to the low voltage operation.This may become one data point for the statistical analysis.

This process may be repeated for all measurements taken after thevoltage conservation is turned on and compared to all similar days inthe historical data taken for the matching season and other weatherconditions. This may produce, for example, seventy-one data points from,for example, thirty days of operation matched with all of the historicalmatching data. The resulting statistical analysis of this data is shownin FIG. 17.

The normality of the data may be validated using the Anderson-DarlingNormality test. In the case of the example of FIGS. 6 and 7, the P-Valuemay be 0.305, which may be well above the required value of 0.02,thereby demonstrating that the data may be normal with an approximately98% confidence level, as shown in FIG. 17. This allows the applicationof a one sample T test to demonstrate the average of the mean value ofthe change in electrical power (MW) to change in voltage. The test maybe performed to evaluate the statistical significance of the averagevalue being above about 0.8. As shown in FIG. 17 the test maydemonstrate an approximately 98% confidence level that the savings inpower to reduction in voltage may be above about 0.8% per 1% of voltagechange.

While the disclosure has been described in terms of exemplaryembodiments, those skilled in the art will recognize that the disclosurecan be practiced with modifications in the spirit and scope of theappended claims. These examples are merely illustrative and are notmeant to be an exhaustive list of all possible designs, embodiments,applications or modifications of the disclosure.

1-38. (canceled)
 39. An electric power control system for an electric power grid configured to supply electric power from a supply point to a plurality of consumption locations, the system comprising: a plurality of sensors, wherein each sensor is located at a respective one of a plurality of distribution locations on the electric power grid at or between the supply point and at least one of the plurality of consumption locations, and wherein each sensor is configured to sense at least one component of the supplied electric power received at the respective distribution location and at least one of the plurality of sensors is configured to generate measurement data based on the sensed component; a controller configured to receive the measurement data from each sensor of a subset of the plurality of sensors, wherein the subset includes more than one and fewer than all of the plurality of sensors for distribution locations receiving the supplied electric power, and to generate an energy delivery parameter based on the measurement data received from the subset; and an adjusting device configured to adjust a component of the electric power supplied at the supply point based on the energy delivery parameter.
 40. The system of claim 39, wherein the subset of sensors comprises the bellwether sensors of the plurality of sensors that have the worst case measured component of electric power.
 41. The system of claim 39, wherein the measured components of electric power comprises at least one of: a voltage; a current; and a phase.
 42. The system of claim 39, wherein the subset includes the sensors sensing the lowest level voltages.
 43. The system of claim 39, wherein the subset includes more than one and substantially fewer than all of the plurality of sensors.
 44. The system of claim 43, wherein the subset includes more than one and substantially fewer than all of the plurality of sensors for distribution locations receiving the supplied electric power.
 45. The system of claim 39, wherein the consumption locations are user locations and the at least one of the plurality of sensors configured to generate measurement data comprises at least one smart meter.
 46. The system of claim 39, wherein the subset includes about twenty sensors on the electric power grid.
 47. The system of claim 39, wherein the controller is configured to: store historical component data that includes at least one of aggregated energy component data at a substation level, and electric power component data at a substation level; determine energy usage at each of the plurality of sensors that are configured to generate measurement data; compare the historical component data to the determined energy usage; and determine energy savings attributable to the system based on the results of the comparison of the historical component data to the determined energy usage.
 48. The system of claim 39, wherein the controller is further configured to generate an energy delivery parameter based on a comparison of the measurement data received from the subset to a controller target voltage band.
 49. The system of claim 39, wherein the energy delivery parameter is generated such that the electric power component remains within a target component band, the target component band being a lower band of a safe nominal operating range.
 50. The system of claim 39, wherein at least one other sensor of the plurality of sensors that is not included in the subset is further configured to send a respective reporting signal to the controller when the electric power component sensed by the sensor is determined to be outside of a respective sensor target component band.
 51. The system of claim 50, wherein the controller is configured such that the at least one other sensor can be added to the subset.
 52. The system of claim 51, wherein the controller is configured to add the at least one other sensor to the subset.
 53. The system of claim 49, wherein the component is voltage and the safe nominal operating range is between about 114V and about 126V and the target component band is between about 114V and about 120V.
 54. The system of claim 39, wherein the supply point is at a transformer at a substation.
 55. The system of claim 39, wherein the sensors of the subset are selected based on predetermined criteria.
 56. The system of claim 55, wherein the predetermined criteria includes historical sensor data.
 57. The system of claim 55, wherein the voltage controller receives measurement data from each sensor of the subset at time intervals having a predetermined length between about 5 seconds and about 15 minutes.
 58. The system of claim 39, wherein the voltage controller receives measurement data from a sensor in response to a request by the controller.
 59. A method for controlling electrical power supplied to a plurality of distribution locations located at or between a supply point and at least one consumption location, each of the plurality of distribution locations including at least one sensor configured to sense at least one component of the supplied electric power received at the respective distribution location and at least one of the plurality of sensors is configured generate measurement data based on the sensed component, the method comprising: receiving measurement data from a subset of the plurality of sensors, wherein the subset includes more than one and fewer than all of the plurality of sensors for distribution locations receiving the supplied electric power; and adjusting a component of the electric power supplied at the supply point based on the measurement data received from the subset.
 60. The method of claim 59, wherein the subset of sensors comprises the bellwether sensors of the plurality of sensors that have the worst case measured component of electric power.
 61. The method of claim 59, wherein the subset includes the sensors sensing the lowest level voltages.
 62. The method of claim 59, wherein the subset includes more than one and substantially fewer than all of the plurality of sensors.
 63. The method of claim 59, further comprising receiving a reporting signal from at least one other sensor of the plurality of sensors that is not included in the subset when the voltage sensed by the other sensor is determined to be outside of a respective sensor target voltage band.
 64. A controller for an electric power grid configured to supply electric power from a supply point to a plurality of consumption locations including a plurality of sensors, wherein each sensor is located at a respective one of a plurality of distribution locations on the electric power grid at or between the supply point and at least one of the plurality of consumption locations, and wherein each sensor is configured to sense at least one component of the supplied electric power received at the respective distribution location and at least one of the plurality of sensors is configured to generate measurement data based on the sensed component, the controller comprising: at least one processor configured to: receive measurement data from a subset of the plurality of sensors, wherein the subset includes more than one and fewer than all of the plurality of sensors for distribution locations receiving the supplied electric power; and adjust a component of the electric power supplied at the supply point based on the measurement data received from the subset.
 65. The controller of claim 64, wherein the subset of sensors comprises the bellwether sensors of the plurality of sensors that have the worst case measured component of electric power.
 66. The controller of claim 64, wherein the subset includes the sensors sensing the lowest level voltages.
 67. The controller of claim 64, wherein the subset includes more than one and substantially fewer than all of the plurality of sensors.
 68. The controller of claim 64, wherein the processor is further configured to receive a reporting signal from at least one other sensor of the plurality of sensors that is not included in the subset when the voltage sensed by the other sensor is determined to be outside of a respective sensor target voltage band. 